Hyper-branched structure—an active carrier for copolymer with surface activity, anti-polyelectrolyte effect and hydrophobic association in enhanced oil recovery

Wu, Qi; Gou, Shaohua; Huang, Jingyun; Fan, Guijuan; Li, Shiwei; Liu, Mengyu

doi:10.1039/c9ra01554j

Cited by 9 publications

(9 citation statements)

References 53 publications

(45 reference statements)

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“…7 The hydrophobic association is an endothermic process, which is boosted by heat intake and enhances the solution viscosity owing to the stretching of the macromolecular chain. 14 The viscosity−shear rate profiles show that the PPG hydrogel exhibits higher viscosity values compared to the PEG hydrogel. This behavior may be justified by increasing the hydrophobic carbon chain in the PPG skeleton, thus giving rise to solution viscosity rather than the PEG hydrogel.…”

Section: Resultsmentioning

confidence: 98%

“…Moreover, the sulfonate groups boost the hydrogen bonding, thus enhancing the solution stability . The hydrophobic association is an endothermic process, which is boosted by heat intake and enhances the solution viscosity owing to the stretching of the macromolecular chain . The viscosity–shear rate profiles show that the PPG hydrogel exhibits higher viscosity values compared to the PEG hydrogel.…”

Section: Resultsmentioning

confidence: 99%

“…Iborra et al 13 studied the emulsifying properties of lauryl methacrylate and poly(ethylene glycol)methylethermethacrylate copolymer, which was prepared through atom-transfer radical copolymerization. Wu et al 14 synthesized hyperbranched copolymers with surface-active properties for enhanced oil recovery. Aktar et al 6 investigated the interaction of poly(ethylene glycol) with Triton X-100 in salt and salt-free solutions.…”

Section: Introductionmentioning

confidence: 99%

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Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

El-hoshoudy

2021

ACS Omega

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Enhanced oil processing aims to retrieve petroleum fluids from depleted reservoirs after traditional processing. Hydrogels and polymeric macromolecules are considered effective displacing agents in oil reservoirs. In the current work, the authors used hydrophilic hydrogels based on poly(ethylene glycol)/poly(propylene glycol) (PEG/PPG) surfmers for oil displacement processes. Statistical modeling of the rheological properties at 80 °C for the two hydrogels indicates that the viscosity–shearing profile obeys the power-law model. Also, shear stress scanning follows the Herschel–Bulkley and the Bingham plastic models. The two hydrogels exhibit an initial yield stress owing to the formation of a three-dimensional (3D) structure at zero shearings. Furthermore, PEG and PPG hydrogels can retain the viscosity after a shear rate of 64.68 S–1. On the scale of surface activity, the two hydrogels exhibit higher surface areas (A m) of 0.1088 and 0.1058 nm2 and lower surface excess concentrations (Γm) of 1.529 and 1.567 × 1010 mol/cm2, respectively. A molecular dynamics (MD) simulation was conducted to explore the Flory–Huggins chi parameter, the solubility parameter, and the cohesive energy density. The results indicate a negative magnitude of chi parameter (χ ij ) for water and salt, which indicates that the two hydrogels have a good tendency toward saline formation water in the underground petroleum reservoir. Furthermore, the dissipative particle dynamics (DPD) was performed on a mesoscale to investigate the interfacial tension, the radius of gyration, the concentration profile, and the radial distribution function. The increased radius of gyration (R g) confirms that the two hydrogels are more overextended and can align perpendicularly toward the water/oil boundary. Experimental displacement was operated on a linear sandpack model using different slug concentrations. The oil recovery factor, the water-cut, and the differential pressure data during the flooding process were estimated as a function of the injected pore volume. The obtained results show that the oil recovery factor reaches 72 and 88% in the cases of PEG and PPG hydrogels at 80 °C with concentrations of 1.0 and 1.5 g/L, which reveals that both hydrogels are effective enhanced oil recovery (EOR) agents for the depleted reservoirs. This study establishes a new route that employs MD and DPD simulation in the field of enhanced oil recovery and the petroleum industry.

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Section: Resultsmentioning

confidence: 98%

Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

El-hoshoudy

2021

ACS Omega

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“…The most common modification in the chitosan structure was to include the branched segments and hydrophobic graft and they became amphiphilic by insertion of the copolymers. [26][27][28][29] A few works aimed to change the capillary force of the reservoir through use the of chitosan derivatives. Fe 3 O 4 @Chitosan nanocomposites were used as EOR additives in the carbonate's reservoir at HPHT conditions.…”

Section: Introductionmentioning

confidence: 99%

Wettability alteration of oil‐wet carbonate rocks by chitosan derivatives for application in enhanced oil recovery II: High‐temperature and high‐pressure conditions—Core flooding tests

dos Santos Francisco,

Maia,

de Almeida Cavadas

et al. 2024

J of Applied Polymer Sci

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Biopolymers, serving as Enhanced Oil Recovery (EOR) agents, are posing challenges and opportunities within the oil industry, particularly in demanding operational conditions. The assessment of trimethyl chitosan (TMC) and its hydrophobized derivative with myristoyl chloride (TMC‐C14) becomes crucial in these rigorous scenarios, presenting a significant challenge for polymer flooding. The study subjected TMC and TMC‐C14 to comprehensive evaluations as EOR agents, employing contact angle measurements, interfacial tension tests using the Drop Shape Analyzer (DSA), and core flood tests under conditions of 60°C, 1000 psi, and elevated salinity. Relative permeabilities were deduced from the results, while spontaneous imbibition tests provided insights into rock wettability. Amott cell tests underscored that both TMC and TMC‐C14 induced accelerated spontaneous oil production within a span of 30 days. Notably, TMC‐C14 exhibited superior interfacial activity compared to TMC, attributed to its hydrophobic segments. The impact on rock wettability was distinct: TMC shifted it towards water‐wet, while TMC‐C14 induced a neutral‐wet condition. This transformation was corroborated by contact angle measurements, imbibition tests, and relative permeability curves. Capillary forces, computed from DSA data and spontaneous imbibition tests, further validated the wettability‐altering tendencies of the chitosan derivatives on the rock. In core flooding tests and relative permeability curves, TMC demonstrated a notable improvement in the recovery factor (RF) compared to seawater. Specifically, RFTMC achieved 69%, surpassing RFbrine at 49%, affirming that the primary mechanism of action for chitosan derivatives lies in their ability to modify rock wettability. This study shows the potential of TMC and TMC‐C14 as effective EOR agents, shedding light on their interfacial activities, impact on rock wettability, and enhanced recovery factors in challenging operational conditions.

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“…The second stage at 250-325C related to the disintegration of the amide groups on the hydrogel chains [5][6] . The third stage at 325-385C corresponds to the complete degradation of other side chain moieties, including sulfonic groups in AMPS and pyrrolidone rings, in addition to the breakdown of carbon-nitrogen bonds [6][7] . The fourth stage occurs at 385-600C and related to the complete degradation and carbonization of the polymer skeleton 6 .…”

Section: Figure S4: 1 H-nmr Of Peg-and Ppg-surfmers and Hydrogelsmentioning

confidence: 99%

Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

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Hyper-branched structure—an active carrier for copolymer with surface activity, anti-polyelectrolyte effect and hydrophobic association in enhanced oil recovery

Abstract: Herein, a hyper-branched polymer h-PMAD with, simultaneously, surface activity, an anti-polyelectrolyte effect and a hydrophobic association was prepared via aqueous solution free radical polymerization, and characterized by IR, NMR, TG–DTG and SEM.

Cited by 9 publications

References 53 publications

Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

Wettability alteration of oil‐wet carbonate rocks by chitosan derivatives for application in enhanced oil recovery II: High‐temperature and high‐pressure conditions—Core flooding tests

Experimental and Theoretical Investigation of Glycol-Based Hydrogels through Waterflooding Processes in Oil Reservoirs Using Molecular Dynamics and Dissipative Particle Dynamics Simulation

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